Greetings, and welcome to Gulfport Energy Corporation Second Quarter Earnings Call. At this time, all participants are in a listen-only mode. A question-and-answer session will follow the formal presentation. [Operator Instructions] As a reminder, this conference is being recorded. I would now like to turn the conference over to your host, Jessica Wills. Please go ahead.

Thank you, and good morning. Welcome to Gulfport Energy Corporation's second quarter of 2017 earnings conference call. I am Jessica Wills, Manager of Investor Relations and Research. Speakers on today's call include Mike Moore, Chief Executive Officer and President; and Keri Crowell, Chief Financial Officer. In addition, with me today and available for the question-and-answer portion of the call are, Mark Malone, Senior Vice President of Operations; Paul Heerwagen, Senior Vice President of Corporate Development and Strategy; Rob Jones, Senior Vice President of Drilling; and Ty Peck, Senior Vice President of Midstream and Marketing. I would like to remind everybody that during this conference call, the participants may make certain forward-looking statements relating to the company's financial condition, results of operations, plans, objectives, future performance and business. We caution you that the actual results could differ materially from those that are indicated in these forward-looking statements due to a variety of factors. Information concerning these factors can be found in the company's filings with the SEC. In addition, we may make reference to other non-GAAP measures. If this occurs, the appropriate reconciliations to the GAAP measures will be posted on our Web site. Yesterday afternoon, Gulfport reported second quarter 2017 net income of $105.9 million or $0.58 per diluted share. These results contain several non-cash items, including an aggregate non-cash derivative gain of $59.9 million, and expense of $1.1 million in connection with the recent SCOOP acquisition, and a loss of $13.3 million in connection with Gulfport's interest in certain equity investments. Comparable to analyst estimates, our adjusted net income for the second quarter of 2017, which excludes all the previous mentioned items, was $60.4 million or $0.33 per diluted share. An updated Gulfport presentation was posted to the website yesterday evening. Please review at your leisure. At this time, I would like to turn the call over to Mike Moore, CEO of Gulfport Energy.

Thank you, Jessica. Welcome, everyone, and thank you all for joining us this morning. As announced in the press release yesterday evening, during the second quarter Gulfport reported approximately $60.4 million of adjusted net income on $264.1 million of adjusted oil and natural gas revenues, and generated approximately $167.3 million of adjusted EBITDA and $145 million of operating cash flow. Gulfport delivered another successful quarter operationally during the second quarter, highlighted by 22% production growth over the first quarter of 2017 and had a very active quarter in both our Utica Shale and SCOOP asset areas. In the Utica Shale the Gulfport team continues to make strides in the field marking the second quarter as the most efficient quarter at the drill bit with respect to spud to rig release and the busiest quarter from a tie in line perspective the company has experienced since earning the play in 2011. In the SCOOP, the integration of the assets is going very well and Gulfport turned to sales are first two operated Woodford completions in the play during the second quarter and continue to be pleased with the results from these wells as we accumulate additional production history. We have been very active on the completion front in the SCOOP, recently beginning flow back on two gross operated Woodford wells and are in various stages of completion on an additional five gross operated Woodford wells. In addition, the team recently spud both the Springer and Sycamore well and is currently drilling ahead on these locations testing new development horizons on the Gulfport acreage. When you couple the strong performance of Gulfport's assets year-to-date and the anticipated activity during the second half of the year, it has led us to increase our 2017 production guidance and we now forecast our 2017 average…

Thanks, Mike. Our success in the field continues to provide support to our financial results highlighted by record corporate production and lower operating cost during the second quarter of 2017. Total net production for the second quarter averaged approximately 1.04 billion cubic feet of gas equivalent per day, a 22% increase sequentially and a 56% increase over the second quarter of 2016. As Mike mentioned, continued strong well performance and robust activity in the Utica Shale led to another solid quarter and has also positioned the company well during the second half of 2017. Our results year-to-date and anticipated activities for the second half of 2017 have led the company to update our 2017 production guidance and we now expect to average approximately 1.065 to 1.1 billion cubic feet of gas equivalent per day. In addition, we currently forecast third quarter production to be approximately 1.17 to 1.18 billion cubic feet of gas equivalent per day, in line with where consensus is today. On the realization front, our second quarter of 2017 realized natural gas price before the effect of hedges and including transportation cost, settled approximately $0.70 per Mcf below the average NYMEX price. We have provided updated realization guidance for the year considering our results year-to-date and utilizing current strip pricing as the various regional pricing points at which the company sells its natural gas, and now forecast our realized natural gas price to average in the range of $0.62 to $0.68 per Mcf, below NYMEX settlement prices in 2017. Before the effect of hedges, our realized oil price came in at $2.96 off WTI and our second quarter realized NGL price came in approximately 39% of WTI. We reiterate our full year guidance for both forecasted oil and NGL realization. Our robust hedge portfolio continues to provide…

In closing, 2017 is a pivotal year for Gulfport. Our 2017 development activities have allowed the company to reach a point financially and operationally where we can provide not only a strong rate of growth for 2017 but we believe places us in a position of growing at a healthy long-term growth rate within operational cash flow. As a result, as we plan for 2018, Gulfport is targeting cash flow neutrality for the calendar year which at today's strip price we estimate would generate approximately 30% growth year-over-year. This concludes our prepared remarks. Thank you, again for joining us for our call today and we look forward to answering your questions. Operator, please open up the phone lines for questions from the participants.

[Operator Instructions] Our first question comes from Neal Dingmann with SunTrust. Please proceed.

Mike, my first question maybe just on those last details you mentioned, on the cash flow neutrality for '18, a 30% growth. Could you talk about what type of rig count are you basing that off of on in both the plays and, again, are you assuming sort of the -- the most recent sort of differentials that you and Ty and everybody laid out.

Well, we are assuming the current strips differential expectations, certainly our hedge book for 2018, you know and I would say, as we look to '18, Neal, obviously we continue to be more efficient in the field. So the truth is, we can do more with less. So I am not going to go into the specific details of how many rigs in each field. But I think you can make the assumption that we probably will have less rigs running.

Okay. And then to your point, I thought that was a good Slide on Slide ten where you laid out some of those Utica wells. Could you talk about on that, just two things there? One, just on the completion, has that changed and just wondering what you are doing there, number one. And then, number two, I know always in the past you always kind of choke those back just because of takeaway to make sure you had adequate takeaway. Maybe if you could have, Rob, or one of the guys jump in, or Mark, somebody talk about just sort of takeaway in how that pertains to the growth in the Utica.

Well, first let me address that. Historically, we haven't actually choked back wells because of takeaway and we had a time where we had a compression issue down in a very isolated area down south, that we had to choke wells back temporarily but never because really of takeaway. And as far as completions and, Mark can jump in too, but I don’t think there is that much of talk about here. We have a mix, really, on the wells that are on that Slide. We have a mix of new and old completions depending on -- and those completions depend on the lease geometry and so we adjust the completions depending on the particular issues that we have at that particular area. So mix of legacy completions and newer completions.

Our next question comes from Tim Rezvan with Mizuho. Please proceed.

I wanted to, first kind of little bit on what Neal had asked about on Slide 10. This seemed an intentional move to kind of highlight the, I guess the consistent results you are seeing in the north and south at Jefferson and Monroe County. So as we look to kind of 2018, how active is your development going to be in these areas. And maybe talk about maybe why you felt the need to kind of highlight the areas or if you feel like there is some kind of disconnect between what you see and what the market things about these areas.

Well, I think several things here. I would say first of all, Tim, we have a lot of wells. And it's just physically impossible to continue to have and show in our presentation individual type curves on every well. So our presentation would be enormous if we continue that. So we are trying to find a way to show well information on a more consolidated basis. Secondly, certainly this time we thought it was important as we had some newer results to show well performance, east to west, north to south, to help the market understand that we are seeing very consistent and encouraging results really across our dry gas acreage. So that was really the idea behind the Slide. And as far as our activities, I guess you will continue to see us focus in the dry gas area, Eastern Belmont, probably next year. Certainly lease explorations will be somewhat of a driver for us next year, but again details to follow on where our specific activities will be.

Okay. Thanks. And then just on my follow-up. What do you see as the run rate to bolt-on additional leases in the SCOOP area? Saw there were some additions recently. How consistently or I guess how competitive is that area getting now?

Well, we were certainly encouraged by what we were able to accomplish this quarter in both SCOOP and Utica, quite frankly, we have lots of brokers out in the field. They are working hard. I think there is some runway. Average cost is still reasonable at $3500 an acre. So I think there is runway, Tim. Time will tell, I guess, about how big that runway is.

Our next question comes from Ron Mills with Johnson Rice. Please proceed.

Maybe one last question on Slide 10. When you look at the spread of those pads from north to south and east to west, any commentary about how some of those wells have performed, especially as you drilled to the northernmost and southernmost tips of your position given the consistency of the results. I'm wondering if some of those are a little bit better as you would have thought some of the acreage grading to shift towards the edges of your position.

Well, you know, I would say we are very encouraged, particularly by the wells in the south. But I think also just the thickness in the north is certainly there. The pressure improves in the south and I think what this chart shows is that although we have nuances, north to south, it's still delivering good wells in all areas.

Okay. And then shifting over to kind of the Springer and Sycamore slides. You talked about the locations of those and on Slide 12 you have the map that kind of shows where they are. When we try to -- is there anything from an analog standpoint, is the Sycamore more potentially prevalent on the central to western part of your position and the Springer more prevalent on the central to eastern part? Or is that just the way industry has drilled so far?

I think it's more indicative of the way industry has drilled so far. Obviously time is going to tell for us but I don’t think there are any conclusions to draw at this point.

And then just that last follow-up on that one would be, what would your eventual plans be for the Springer and Sycamore given the Woodford kind of 20% plus above plans? When you think the longer term, how do you think about fitting those incremental zones into a development program? And that's it.

Well, that’s a good question. And I think one of the reasons, Ron, that we were excited to be able to push forward the development of the Springer and the Sycamore is so that we could think about what level of activities in those horizons we should have in our 2018 plan. So I can't tell you how much it's going to be yet. Certainly it's an economic decision, it's optionality and it's whatever brings us the highest value well. So we will have to see what we have. We will continue to watch the peers and fortunately we should have information in time to be able to include some of that in our 2018 activity, if that’s what we decide to do.

Thank you. Our next question comes from David Deckelbaum with KeyBanc Capital Markets.

My question, again, I guess is on the '18 plan, as you mentioned that before Q&A started. Can you kind of give us a little bit of color what the thought process is here and you obviously have the balance sheet and liquidity. At strip you are developing wells with very competitive returns. Is free cash neutrality more of a philosophical goal for the company now on sort of a repeatable basis and that’s sort of the best way you think that there is to create value for shareholders. And then, I guess, if you could add any color on, would there be things that you do, does that free cash neutrality describe the E&P program and this is excluding midstream and leasehold spend.

Yes. Those are all good questions. So it is, we do think about cash flow neutrality in terms of our D&C budget. Obviously, the other spends are minimal. Midstream certainly minimal. Land, while we have some minimum commitments, discretionary spends on land would only be funded with other liquidity sources. So really we are talking about the bulk of our budget and cash flow neutrality. Listen we think it's something that all companies should aspire to. We have actually worked towards this for a long time. David, it's been a goal of ours. With the level of activities that we have this year, it certainly propels us nicely into 2018 and sets us up to deliver, to be able to deliver approximately 30% growth in a cash flow neutral way. But we also think it's something that we can sustain going forward in future years. So we are not just talking about '18, we are talking about '19, '20 and beyond. And we think we can deliver sustained double-digit in a cash flow neutral way going forward as well.

Okay. I appreciate that color, Mike. Does that change, I guess the type of program that you are running, at all? I know that you alluded to, you can do more with less. Is that the suggestion that you would just be more in development mode using larger projects and that there would be fewer one off rigs, or that you would be targeting the most efficient areas? Is there a change versus what you would be doing, say, the first half of this year, other than some of the SCOOP delineation and HBP?

I don’t think so. I think we consider ourselves kind of in development mode and have for some time now. So I am not sure it fundamentally changes the way we think about the choices that we make for our programs. So I don’t think so, David.

Okay. And I could just sneak in one another one. You guys have, I guess, several different non-core assets or other sources of funds. I guess they would be coming to you, Strike Force JV etcetera. Can you go over some of the timing of when you would expect seeing some proceeds coming in the door from some of these sort of various opportunities that you have out there and, I guess, naturally you would be thinking of using those funds for some of the other things that you alluded like leasehold spend etcetera.

Yes. Obviously, we have lots of -- since we are targeting cash flow neutrality for our D&C budget, we have lots of options actually for those other liquidity sources. Mammoth, no plans there. It's just about what the right time is, what brings the most value to our shareholders. And so, no, specific thoughts or plans there. The Strike Force asset, I am probably limited on what I can say. I think it's kind of tail on the dog but seems like there has been some messaging that could be a 2018 event. But we are not counting those sources into our liquidity sources for 2018. So I know I am being vague here but there is no -- I guess, what I am trying to say is, there is no pressure for us, there is no guarantor ahead and we have lots of options that we can think about when and if those -- the timing is right on those.

Our next question comes from James Sullivan with Alembic Global Advisors. Please go ahead.

To quick ones from me. You alluded to pipeline tie in there in November of '17 with 2 Bcf a day as incremental capacity out of Appalachia. Just wanted to clarify, are you talking about [rain leech] [ph] there? And then maybe a smattering of all the smaller ones to get you up to the 2 Bcf a day?

Yes. This is Ty. I mean we are talking about the TransCanada project as well as to expect to having a number of expansions on [Petco] [ph] system. So that gives us that 2 Bcf.

Got you. Just wanted to confirm that. Thanks. And then I know you guys didn’t give a half year update on reserves or anything but can you guys just give a feel for what kind of TDP growth you have seen at midyear, with your activity being placed around in Q2. And I am just thinking about how that feed into your discussions with your bank group or in the borrowing base going into October.

Sure. This is Keri. You have seen our activity on 2Q, our turn in lines, and we expect around the same activity in the third quarter. So we do expect a large increase in our PDP coming up on our next re-determination. We can't speak to where price [decks] [ph] will be but we do anticipate a large increase in our PDP reserves.

Okay. Great. So no sense of where you guys are at at midyear, I think?

Not that we can address. No.

Next question comes from Geoff Jacques with Iberia Capital Partners. Please go ahead.

Just looking at the SCOOP, from the drilling days, I know it's still early days and you guys are just getting a handle on the acreage. But is there some type of target or something that you guys are looking to in '18 or beyond?

Geoff, this is Rob. On the drilling days in the SCOOP, first thing is that it has proved to be challenging, just as advertised. We have been able to drill wells and in the similar days as most of our peers. Going forward, certainly we are making lots of changes. We have upgraded some equipment. We have changed out some personnel. So we are making lots of strides. The equipment we have upgraded, we are very pleased with. And in the future we expect the days to come down and that’s certainly the goal with what we do in the drilling group.

And I would add to that, I think both groups, drilling and completion, have been working extremely hard here in the SCOOP. And as you probably recall, early days in the Utica, we were not that efficient and it took us a while to get down to the new records that both of our groups are setting today. It feels like in SCOOP that we are making progress much more quickly the last, I would say the last six weeks, we feel like we have turned a corner with all the changes that have been implemented on both the drilling and completion side through [indiscernible] programs, through liners, through all kinds of things. The high grading of equipment. And so we are already beginning to see lots of improvement out there. As to where we get next year, it's hard to quantify exactly but we are convinced that we are going to be much more efficient, not only in the back half of this year but '18 over '17.

Thank you. I would now like to turn the call back over to Michael Moore for closing comments.

We appreciate your time and interest today. Should you have any questions, please do not hesitate to reach out to our investor relations team. Thank you and this concludes our call.